US10794156B2 - Multi-bore jumper interface - Google Patents
Multi-bore jumper interface Download PDFInfo
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- US10794156B2 US10794156B2 US15/840,593 US201715840593A US10794156B2 US 10794156 B2 US10794156 B2 US 10794156B2 US 201715840593 A US201715840593 A US 201715840593A US 10794156 B2 US10794156 B2 US 10794156B2
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
- E21B33/0387—Hydraulic stab connectors
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/013—Connecting a production flow line to an underwater well head
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/18—Pipes provided with plural fluid passages
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/0107—Connecting of flow lines to offshore structures
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L1/00—Laying or reclaiming pipes; Repairing or joining pipes on or under water
- F16L1/26—Repairing or joining pipes on or under water
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
- E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L3/00—Supports for pipes, cables or protective tubing, e.g. hangers, holders, clamps, cleats, clips, brackets
- F16L3/16—Supports for pipes, cables or protective tubing, e.g. hangers, holders, clamps, cleats, clips, brackets with special provision allowing movement of the pipe
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L9/00—Rigid pipes
- F16L9/18—Double-walled pipes; Multi-channel pipes or pipe assemblies
- F16L9/19—Multi-channel pipes or pipe assemblies
- F16L9/20—Pipe assemblies
Definitions
- Such subsea oilfields may accommodate a host of permanently installed equipment at the seabed.
- a host of pumps, manifolds, storage units and other equipment may be distributed about the oilfield according to the designated layout for the site.
- This designated layout will generally include hydraulic communication between each tree and a manifold. In this way hydrocarbon production may be routed through the manifold which more specifically directs the production upstream.
- a pipe referred to as a “jumper”, is generally the tubular structure that is placed between the tree and the manifold to allow the production to travel from the tree to the manifold as indicated.
- jumpers may also be utilized in other applications.
- a jumper pipe may include a simple mono-bore to serve as the conduit through which the production travels. In these circumstances, the presence of a single fluid conduit means that orienting the ends of the jumper for coupling to each of the tree at one end and the manifold at the other does not present any unique challenges.
- the manifold also serves as an interface through which other hydraulics may be directed at the tree and well.
- a host of added hydraulics beyond the central bore for the production may be provided.
- additional bores may be provided to allow chemical injection or other treatment fluids.
- Added bores may also be provided as a means of allowing for hydraulic control over downhole features, for example to open and close different valves in the well or on the tree, or to deploy instrumentation or for a variety of other purposes.
- the end faces of the jumper include the termination for the central bore as well as terminations for a host of other, generally smaller, bores at perimeter locations of the jumper.
- orienting and aligning the end faces of the jumper for proper securing to the coupling locations at each of the tree and the manifold presents a unique challenge.
- the central bore portion of the jumper is generally a 6-8 inch pipe, it is a fairly rigid structure, generally weighing in the tens of thousands of pounds and spanning a distance of about 75 feet or so between the tree and manifold.
- twisting in order to attain proper alignment is a challenging undertaking for any type of jumper due to the inherent inflexibility.
- they are specially configured with a host of twists and turns. That is, as opposed to merely utilizing straight tubular piping between the tree and the manifold, a host of bends will be introduced to the jumper, resulting in a multi-planar jumper of complex corkscrew-type geometry. In this way, once one end is aligned and secured, for example, at the tree, the other end may be twisted to a degree as necessary for bore alignment with the interface at the manifold.
- this horizontal multi-bore jumper may be massive in size. For example, even though the tree and manifold might be separated by 75 feet, the jumper may be 180 feet. This adds to material cost and makes deployment and installation much more of a challenge. Unlike a vertical jumper, the barge delivering the horizontal jumper is unlikely to be able to accommodate several such jumpers. Once more, the jumper requires a significant amount of footspace on the sea bed between the tree and manifold. Thus, other lines and equipment may need to be relocated. Nevertheless, as a practical matter, the massive corkscrew type of horizontal jumper remains the only practical option where multi-bore jumpers are to be utilized.
- An interface for coupling a multi-bore jumper to equipment at a seabed.
- the interface includes a rotatable hub with a central location and a central bore that terminates adjacent this location. However, the hub is rotatable independent of the central bore.
- the interface also includes at least one perimeter bore which terminates at a perimeter location of the plate and being movable with the plate during any rotation thereof.
- FIG. 1A is a front view of an embodiment of a multi-bore interface for a subsea jumper.
- FIG. 1B is a front view of an embodiment of a rotatable hub for coupling to the multi-bore interface of FIG. 1A .
- FIG. 2 is a side perspective sectional view of an embodiment of a subsea jumper employing a multi-bore interface.
- FIG. 3 is a perspective view of an embodiment of a subsea jumper employing a multi-bore interface.
- FIG. 4A is an overview depiction of an embodiment of a vertical subsea jumper with a multi-bore interface being delivered to an oilfield.
- FIG. 4B is an overview depiction of the vertical subsea jumper of FIG. 4A being coupled to equipment at the oilfield.
- FIG. 4C is an overview depiction of the vertical subsea jumper of FIGS. 4A and 4B upon completed installation at the equipment of the oilfield.
- FIG. 5 is a flow-chart summarizing an embodiment of coupling a subsea jumper with a multi-bore interface to equipment at a seabed.
- Embodiments are described with reference to certain subsea operations utilizing manifolds which are fluidly coupled to trees at a seabed.
- production that is drawn from a well and through the tree may be routed through the manifold for directing production.
- Additional bores, beyond the central production bore, may be found in the jumper which fluidly couples the tree and manifold.
- hydraulic control, chemical injection and other applications may be directed at the tree through the manifold.
- this particular type of system between a tree and manifold is described, such a multi-bore jumper may be utilized to connect a variety of other types of equipment at the seabed. Regardless, so long as the jumper or the equipment includes an interface with a hub accommodating bores which are able to be rotated independent of the central bore, appreciable benefit may be realized.
- FIG. 1A a front view of an embodiment of a multi-bore interface 100 for a subsea jumper is shown.
- the interface 100 is equipped with a connection head 130 that accommodates a rotatable hub 125 that is independently disposed about a central bore 175 .
- the central bore 175 may be a 4-12 inch diameter production pipe about which the hub 125 may freely rotate within certain tolerances. That is, rotation of the hub 125 is not impeded by the connection head 130 and outer surrounding structure, nor is it impeded by the inner adjacent structure of the central bore 175 .
- the rotatable hub 125 includes locations where perimeter bores ( 140 , 160 ) terminate.
- the visible terminal ends of these bores 140 , 160 may be in the form of male couplers.
- corresponding female couplers 145 , 165 may be provided at a seal plate 180 of subsea equipment to which the interface 100 is to be secured (see FIG. 1B ).
- the male and female nature of the couplers 140 , 160 , 145 , 165 may be reversed or other suitable coupling configurations employed.
- the terminal ends depicted are the terminal ends of electric 140 and hydraulic 160 bores.
- these bores are provided to serve as a conduit for electric 140 or hydraulic 160 control over equipment features, for example, once the interface 100 is fully coupled to subsea equipment such as a tree 425 or manifold 450 (see FIGS. 4A-4C ).
- perimeter bores 140 , 160 may be present for other purposes such as power storage, communications, gas lift, pressurization, chemical injection, and a variety of other applications
- the perimeter bores 140 , 160 are smaller and more flexible than the central production bore 175 .
- the perimeter bores 140 , 160 may be 1 inch or less in diameter.
- alignment pins 150 extend from the hub 125 . These pins 150 may be referred to as “fine” alignment pins 150 in contrast to other types of alignment aids that may be used to initially orient the interface 100 relative the seal plate 180 prior to the more precise alignment provided by the depicted pins 150 .
- an ROV, funneling structure and other forms of guidance may be provided as a jumper 200 and interface 100 are brought to the seal plate 180 of subsea equipment (e.g. see FIGS. 2 and 4A-4C ).
- FIG. 1B a front view of an embodiment of the above referenced seal plate 180 is shown.
- the seal plate 180 is the location of the subsea equipment to which the interface 100 of FIG. 1A may be securely coupled.
- the orifices 155 which are provided to accommodate the alignment pins 150 of FIG. 1A . That is, as the pins 150 are brought into the vicinity of, and enter the orifices 155 , the pins 150 may be moved by a funneling shape of each orifice 155 as it extends below the surface of the plate 180 . Notice that each orifice 155 is considerably larger diameter at the surface of the plate 180 than the pins 150 .
- the orifices 155 may funnel to a degree having an initial diameter that is slightly larger than the diameter of the pins 150 .
- the pins 150 may taper near the ends. In this manner, the odds of initial engagement between the ends of the pins 150 and the orifices 155 are enhanced. Following this engagement, the continued downward movement of the pins 150 may result in funneling the pins toward a more centered alignment within the orifices 155 .
- a keyed split ring or other stop device may be incorporated into the interface 100 between the hub 125 and the central production bore 175 to prevent over rotation. That is, while it may be of benefit to allow for a few degrees of corrective rotation, it may also be of benefit to the integrity of the perimeter bores 140 , 160 , that the amount of torsional load from the rotation be kept to a practical minimum as discussed further below.
- the pins 150 , bores 140 , 160 and the entire hub 125 are rotatable about the production bore 175 as indicated.
- the pins 150 extend out further than the terminal ends of the perimeter bores 140 , 160 from the base of the hub 125 . In this way, the described corrective rotating may take place before the terminal ends of the bores 140 , 160 are to mate with the corresponding female couplers 145 , 165 of the seal plate 180 .
- FIG. 2 a side perspective sectional view of an embodiment of a subsea jumper 200 is shown which employs the multi-bore interface 100 of FIG. 1A .
- the front face of the interface 100 is out of view allowing the perimeter bores 140 , 160 and the central bore 175 to be visible from the opposite side of the interface 100 from that of FIG. 1A .
- the bores 140 , 160 , 175 are shown emerging from a housing 250 adjacent the connection head 130 prior to the addition of protective casing 300 as shown in FIG. 3 .
- the region 275 which is to be surrounded by protective casing 300 may be occupied by insulating material, in addition to the bores 140 , 160 , 175 .
- any twisting or rotation of the hub 125 is unlikely to have any effect on the position or orientation of the perimeter bores 140 , 160 in this region 275 .
- the housing 250 may be intentionally void of insulation near perimeter locations. Thus, rotating of the hub 125 may translate into twisting of perimeter bores 140 , 160 within the housing.
- This twisting may be translated across several feet of the length, as the bores 140 , 160 run across the interior of the housing 250 . In the embodiment shown, this distance may be between about 2-4 feet (e.g. the length of the housing 250 ).
- the rotation of the hub 125 to attain proper mating alignment may be no more than a few degrees, limiting this added freedom of movement for the bores 140 , 160 to the corresponding length of the housing 250 should be sufficient.
- the indicated void space may be extended beyond the housing 250 to facilitate perimeter bore twisting across greater distances if so desired.
- FIG. 3 a perspective view of an embodiment of a subsea jumper 200 is shown which employs a multi-bore interface 100 as detailed above.
- the fully assembled jumper 200 is configured to provide a multi-bore bridge between two different pieces of equipment at a seabed 400 .
- the likelihood that both interfaces 100 will be perfectly aligned with both seal plates 180 for coupling are somewhat remote (see FIGS. 1A and 1B ). That said, through detailed planning, architecture, mapping and installation techniques, the misalignment between the interfaces 100 and seal plates 180 should generally be well below 5°.
- the rotatable multi-bore hub 125 has been provided for each jumper interface 100 .
- the jumper 200 is shown with protective casing 300 that extends from the housing 250 that leads to the connection head 130 .
- the described interface 100 is outfitted with the rotatable hub 125 . More specifically, the hub 125 may be rotated as alignment pins 150 begin to make their way into funnel shaped orifices 155 of the seal plate 180 at seabed equipment 425 , 450 (see FIGS. 1B and 4A ). Thus, even if the pins 150 are off center or misaligned as they begin to traverse the orifices 155 , the hubs 125 at each interface 100 may begin to rotate, bringing the perimeter bores 140 , 160 into alignment with corresponding couplers 145 , 165 (again, see FIGS. 1B and 4A ).
- FIG. 4A an overview depiction of an embodiment of a vertical “M-shaped” subsea jumper 200 is shown with multi-bore interfaces 100 at each end thereof as it is being delivered to an oilfield. Though, a half “M-shaped” configuration may also be utilized. As discussed above, because potential multi-bore misalignment need not be addressed through an extended length horizontal jumper having built in twists and turns, a much smaller profile may be used for the jumper 200 . For example, in the embodiment shown, the tree 425 may be distanced from the manifold 450 by about 75 feet. However, the entire length of the jumper 200 , including the depicted vertical portions will be less than 150 feet. That is, the jumper 200 may be of a length that is less than twice the distance separating the equipment ( 425 , 450 ).
- a single support beam 480 may be used to lower the jumper 200 from a delivery vessel at a sea surface above.
- Positioning aids such as the depicted remote operated vehicle (ROV) 475 may be provided to support visual and, if need be, interventional, assistance as the jumper 200 is lowered.
- ROV remote operated vehicle
- the amount of footspace required at the delivery vessel is also limited.
- the vessel may accommodate a host of other equipment to be installed at the seabed 400 .
- several such jumpers 200 may be loaded onto the same vessel. This is in stark contrast to the large scale horizontal corkscrew type of jumpers which are otherwise utilized where multi-bore functionality is sought. From manufacture to transportation to installation, appreciable benefit may be realized from utilizing a multi-bore jumper 200 with rotatable hubs 125 at each interface 100 (see FIG. 1A ).
- FIG. 4B an overview depiction of the vertical subsea jumper 200 of FIG. 4A is shown as it is coupled to equipment 425 , 450 at the oilfield.
- the alignment pins 150 are received by the orifices 155 of the plates 180 .
- additional pins and larger funneling orifice structures may be utilized as a preliminary form of guidance in directing the pins 150 toward the orifices 155 .
- the ROV 475 may be utilized to provide added guidance as indicated above.
- rotation of the hubs 125 may take place as indicated at each of the interfaces 100 . This may include rotation taking place at each hub 125 in roughly equal measure. So, for example, where alignment of one interface 100 would result in a 5° misalignment of the other interface 100 , the completed coupling of the interfaces 100 to the equipment 425 , 450 may actually result in a 21 ⁇ 2° rotation for each hub 125 .
- the amount of torque that is placed on each of the perimeter bores 140 , 160 at each end of the jumper 200 is limited to a shared overall amount and the hubs 125 have no measurable torsional load during installation due to this architecture.
- FIG. 4C an overview depiction of the vertical subsea jumper of FIGS. 4A and 4B is shown upon completed installation at the equipment 425 , 450 of the oilfield.
- a protective cover 460 has been placed over the coupled interface 100 .
- a permanent multi-bore link between the equipment has been provided in the form of the practical low profile jumper 200 .
- the smaller size of the jumper 200 means that it may be kept off of the seabed 400 .
- the jumper 200 leaves room for any other lines, cables, hydraulics and other items that are often run across the seabed 400 , depending on the oilfield layout.
- FIG. 5 a flow-chart summarizing an embodiment of coupling a vertical subsea jumper with a multi-bore interface to equipment at a seabed.
- the jumper may be lowered to the location of the equipment by way of gravity as indicated at 515 .
- first and second interfaces of the jumper may be secured to first and second pieces of equipment (see 530 , 545 ).
- this securing may include rotating a hub of the first and second interfaces as needed in order to align perimeter bores of the interfaces with couplings of each piece of equipment. Regardless, once this is securely completed and the jumper fully installed, operating over multiple bores between the pieces of equipment may take place as noted at 590 .
- Embodiments described above provide a multi-bore vertical jumper that may be of low profile, reduced weight and practically installed. Concern over misalignment or undue torque being placed on such a jumper in order to correct alignment is minimized. Reduced costs in terms of manufacture, transportation and installation. Indeed, even after installation, benefit may be realized in utilizing a low profile jumper that may be kept off of the seabed safeguarding and allowing room for other lines or equipment thereunder.
- the interface with rotating hub is described herein as being incorporated into the jumper.
- the seal plate may be incorporated into the jumper or, if so desired, both the seabed equipment and the jumper may make use of interfaces with rotating hubs for coupling to one another.
- the concepts detailed herein may be incorporated into tie-ins other than jumpers.
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Abstract
Description
Claims (17)
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US15/840,593 US10794156B2 (en) | 2017-12-13 | 2017-12-13 | Multi-bore jumper interface |
EP18211118.7A EP3498969B1 (en) | 2017-12-13 | 2018-12-07 | Multi-bore jumper interface |
Applications Claiming Priority (1)
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US15/840,593 US10794156B2 (en) | 2017-12-13 | 2017-12-13 | Multi-bore jumper interface |
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US20190178060A1 US20190178060A1 (en) | 2019-06-13 |
US10794156B2 true US10794156B2 (en) | 2020-10-06 |
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US15/840,593 Active US10794156B2 (en) | 2017-12-13 | 2017-12-13 | Multi-bore jumper interface |
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Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20220154545A1 (en) * | 2020-11-13 | 2022-05-19 | Onesubsea Ip Uk Limited | Configurable coupling assembly |
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2017
- 2017-12-13 US US15/840,593 patent/US10794156B2/en active Active
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2018
- 2018-12-07 EP EP18211118.7A patent/EP3498969B1/en active Active
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US4086778A (en) | 1977-01-06 | 1978-05-02 | Mobil Oil Corporation | Subsea connection unit |
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US11719065B2 (en) * | 2020-11-13 | 2023-08-08 | Onesubsea Ip Uk Limited | Configurable coupling assembly |
Also Published As
Publication number | Publication date |
---|---|
EP3498969A1 (en) | 2019-06-19 |
US20190178060A1 (en) | 2019-06-13 |
EP3498969B1 (en) | 2024-04-17 |
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